|Publication number||US7775276 B2|
|Application number||US 11/367,924|
|Publication date||Aug 17, 2010|
|Priority date||Mar 3, 2006|
|Also published as||US20070205021|
|Publication number||11367924, 367924, US 7775276 B2, US 7775276B2, US-B2-7775276, US7775276 B2, US7775276B2|
|Inventors||Michael T. Pelletier, John C. Welch, Clive Menezes|
|Original Assignee||Halliburton Energy Services, Inc.|
|Export Citation||BiBTeX, EndNote, RefMan|
|Patent Citations (38), Referenced by (7), Classifications (10), Legal Events (3)|
|External Links: USPTO, USPTO Assignment, Espacenet|
The application relates generally to sampling, more particularly, to sampling in well drilling operations.
Monitoring of various parameters and conditions downhole during drilling operations is important in locating and retrieving hydrocarbons, such as oil and gas, from downhole. Monitoring of the parameters and conditions downhole is commonly defined as “logging.” Boreholes are drilled through various formations at different levels of temperature/pressure to locate and retrieve hydrocarbons. Accordingly, a number of different sensors and testers are used to monitor the parameters and conditions downhole, including the temperature and pressure, the various characteristics of the subsurface formations (such as resistivity and porosity), the characteristics of the borehole (e.g., size, shape), etc. Such sensors may include electromagnetic propagation sensors, nuclear sensors, acoustic sensors, pressure sensors, temperature sensors, etc. The data generated from the measurements by these sensors can become voluminous (e.g., data related to sonic and imaging information). It is also desirable to sample formation fluids to make decisions on the economic value and manage the reservoir. Samples have been taken down hole, at a separator or in a stock tank. Then samples are shipped to a laboratory, where the fluid is reconstituted to the reservoir conditions. The sample is then separated into a liquid component and a gas component for gas chromatography analysis. It is desirable to extract samples directly from the formation. In this end, formation testers were developed that place a seal on the formation wall and extract fluid from the formation and use the sampled fluids in wireline testing devices. See U.S. Pat. Nos. 5,230,244; 6,843,118; 6,658,930; 6,301,959; and 5,644,076, all assigned to the assignee of the present application and all herein incorporated by reference. Typically testing devices produce samples that must be pumped back to the surface and then tested. Other typical testing devices test downhole and the resulting data is transmitted back to the surface.
Typically, such data and samples may initially be stored in various components downhole. The data is then downloaded from these components to a computing device on the surface for analysis and possible modifications to the current drilling operations. The samples are carried to the surface for testing. A current approach for downloading of this data includes the use of low data rate electrical connections after the downhole drilling tools are pulled out of the borehole. The fluid samples are acquired when the drill string is removed from the bore hole and a wireline tester is inserted into the bore hole.
Embodiments of the invention may be best understood by referring to the following description and accompanying drawings which illustrate such embodiments. The reference numbers are the same for those elements that are the same or similar across different Figures. In the drawings:
Methods, apparatus, and systems for formation fluid sampling, for example with formation tester on a bottom hole assembly (such as a downhole drilling tool) are described. In the following description, numerous specific details are set forth. However, it is understood that embodiments of the invention may be practiced without these specific details. In other instances, well-known circuits, structures, and techniques have not been shown in detail in order not to obscure the understanding of this description.
During drilling operations, the drill string 108 (including the Kelly 116, the drill pipe 118 and the bottom hole assembly 120) is rotated by the rotary table 110. In addition or alternatively to such rotation, the bottom hole assembly 120 may also be rotated by a motor (not shown) that is downhole. The drill collars 122 may be used to add weight to the drill bit 126. The drill collars 122 also may stiffen the bottom hole assembly 120 to allow the bottom hole assembly 120 to transfer weight to the drill bit 126. Accordingly, this weight provided by the drill collars 122 also assists the drill bit 126 in the penetration of the surface 104 and the subsurface formations 114.
During drilling operations, a mud pump 132 pumps drilling fluid (known as “drilling mud”) from a mud pit 134 through a hose 136 into the drill pipe 118 down to the drill bit 126. The drilling fluid can flow out from the drill bit 126 and return back to the surface through an annular area 140 between the drill pipe 118 and the sides of the borehole 112. A hose or pipe 137 returns the drilling fluid to the mud pit 134, where such fluid is filtered. Accordingly, the drilling fluid can cool the drill bit 126 as well as provide for lubrication of the drill bit 126 during the drilling operation. Additionally, the drilling fluid removes the cuttings of the subsurface formations 114 created by the drill bit 126.
Downhole tool 124 includes, in various embodiments, one to a number of different downhole sensors 145, which monitor different downhole parameters and generate data that is stored within one or more different storage mediums within the downhole tool 124. The type of downhole tool 124, and the type of sensors 145 thereon, depend on the type of downhole parameters being measured. Such parameters may include the downhole temperature and pressure, the various characteristics of the subsurface formations (such as resistivity, radiation, density, and porosity), the characteristics of the borehole (e.g., size, shape, and other dimensions), etc. The downhole tool 124 further includes a power source 149, such as a battery or generator. A generator could be powered either hydraulically or by the rotary power of the drill string. The downhole tool 124 includes a formation testing tool 150, which can be powered by power source 149. In an embodiment, the formation testing tool 150 is mounted on a drill collar 122. The formation testing tool 150 engages the wall of the borehole 112 and extracts a sample of the fluid in the adjacent formation. As will be described later in greater detail, the formation testing tool 150 samples the formation and inserts a fluid sample in a sample carrier 155. The size of the sample carrier(s) 155 are shown on an enlarged scale in
In an embodiment, the down hole tool 124 is coupled to a computing/storage device through a cable that may include optical signal carrier(s) (e.g., fiber optic cable) and electrical signal carrier(s) (e.g., electrical wire). A cable that includes both fiber and wire is referred to as a hybrid cable. The electrical signal carrier(s) therein may be used to provide low-voltage power (e.g., less than about 12 volts and may be intrinsically barriered) to the electronics within the downhole tool 124 to power electronics necessary for the download or upload of data. The electrical signal carrier(s) may also be used as slow speed communication media. The optical signal carrier(s) is used to provide the communication medium for the downloading and uploading of the data. Accordingly, optical (and not electrical) communications are used as data communications within an ambient environment that may include combustible/ignitable gases (e.g., a Class I, Division 1 Area, Zone 0 or Zone 1).
In operation, the piston 208 drives the snorkel 215 into contact with the subsurface formation 114. In the illustrated embodiment, the snorkel 215 penetrates into the formation 114. In an embodiment, the snorkel 215 contacts the formation wall but does not penetrate into the formation 114. The sampling system 230 induces a reduced pressure in the sample line 217 that is less than the fluid pressure in the formation. Accordingly, fluids flow from the formation into the apertures of the snorkel 215 and into the sample line 217. The sample line 217 delivers fluid to be sampled into the carrier loader 225. The carrier loader 225 loads fluid samples into sample carrier(s) 155. Carrier loader 225 releases, in an embodiment, the loaded sample carrier into the mud stream. In a further embodiment, the carrier loader returns the loaded sample carrier to its storage location, (e.g., in a magazine or other carrier holder). Structure and operation of the carrier loader 225 will be explained in greater detail below. It will be understood that the sampling system 230 includes a computer and/or other control systems to control the tool hydraulic system 210 and the carrier loader 225 in an embodiment.
The jacket 505 includes an identifier 508 that uniquely identifies the sample carrier relative to the other sample carriers. The identifier 508 is a unique code, such as a mechanical code, electrical code, or electrochemical code. In an embodiment, the identifier is a bar code imprinted on the jacket 505. In an embodiment, the identifier is a radio frequency identification tag (“RFID”) mounted in the jacket 505. RFID is a read-write integrated circuit in an example. The RFID is 2.5 mm×2.5 mm and can store at least a kilobyte of digital information. It will be recognized that in some applications of the sample carrier it is desirable to have storage of greater than one kilobyte. The RFID further includes an on-board antenna to enable wireless RF communication. Thus, the RFID can act as a stand alone data carrier. Accordingly, the sample carrier 155 can carry data stored in the RFID chip back to the surface in addition to carrying fluid samples. In an embodiment, the downhole tool 124 writes data, for example, data acquired by its sensors, to the RFID before the sample carrier is ejected into the mud stream. Examples of data include tens of feet of gamma logs, temperature, pressure, depth, flow rates, density, sensed formation properties, viscosity, contamination levels, and any other data measured down hole. It will further be recognized that other types of data storage that could be integrated into the sample carrier 155 is within the scope of the present invention. Such data storage provides adequate communication bandwidth for measurement-while-drilling applications.
The sample carrier 155 is constructed of any suitable material (e.g., aluminum, steel, titanium, etc.) that can withstand the rigors of its environment. The sample carrier 155 is constructed to withstand pressures of at least 30,000 psi and temperatures up to about 500 degrees F. In an embodiment, the sample carrier 155 is, at least partly, constructed of a semicompliant material, such as a resilient polymer. The sample carrier 155 has a size that enables it to be positioned in a producing formation or in an annulus between a well casing and a well bore such that it is freely movable therein. That is, the smooth, rounded outer surface (i.e., barrel shape) and dimension of the carrier ensure that it does not bridge the space from the bore hole wall to the drill string, and will not snag on bore hole wall or drill string. In an embodiment, the carrier 155 has a length of about ⅝ inch, which is its largest dimension. The width of the carrier is less than the length, for example, 0.5 inch or less, in an embodiment. While the shape of the sample carrier 155 is illustrated as oblate, other embodiments of generally spherical or generally prolate spherical shapes are also well-suited for the sample carrier 155. It will be recognized that any shape that will accommodate the necessary volume for holding a sample and facilitate placing the carrier 155 down the bore and into the mud stream may be used as well. As the carrier 155 is released into the mud stream, it is desirable that the carrier 155 be drillable so that in the event a carrier 155 in the mud stream contacts the drill bit 126, the carrier will not interfere with the operation of the drill bit. It will be recognized that the disclosed dimensions for parts of the carrier 155 may be modified for different drilling environments. In any event, it is desirable for the carrier 155 to have a density similar to, or less than, the density of drill cuttings. For example, drill cuttings that have a density of about 2.6 gm/cc are brought to the surface by a combination of mud flow and rheology of the mud system. Accordingly, the carrier 155 should have about the same, or less, density as the drill cutting. In this example, the carrier 155 with sample should have a density of less than about 2.6 gm/cc.
In an embodiment, the carrier 155 includes a chemical coating that attaches to a particular substance (e.g., a hydrocarbon). In an embodiment, the jacket 505 includes the coating. In an embodiment, the mandrel 300 includes the chemical coating 345 (
Carrier loader 225 has a drive assembly 610 and a loading assembly 620. The drive assembly 610 includes a movable drive collar 612 with a center aperture and a plunger 614 journaled through the center aperture of collar 612. Collar 612 has an engagement side that generally matches the outer dimensions of one side of the carrier 155. The plunger 614 has a diameter generally equal to or less than the diameter of the mandrel 300 at least over an end segment of the plunger 614. This end segment has a seal 616 adjacent its end. Drive assembly 610 further includes a drive for laterally moving the collar 612 and plunger 614. The drive assembly 610 may powered by electrical power, e.g., a battery or wireline power in an embodiment. Drive assembly 610 is hydraulically powered in an embodiment. The drive assembly 610 can also be powered by a pneumatic system. Any of these systems can be powered by the rotary movement of the drill string 108 or flow of the mud stream.
Loading assembly 620 includes a receiving collar 622 with a beveled sealing face for sealing contact with the beveled face of the sleeve 400. Receiving collar 622 has a vertical aperture therethrough. The vertical aperture defines a segment of the sample line 217. Receiving collar 622 includes a further aperture generally perpendicularly crossing the vertical aperture and extending through the collar 622. A journal bushing 624 is fixed in the further aperture. Journal bushing 624 has a vertical aperture coaxial with the sample line aperture in the collar 622 and a longitudinally extending center aperture that is coaxially aligned with the center aperture of drive collar 612. A sample port is defined in the bushing 624 at the intersection of the two apertures of receiving collar 622. The receiving collar 622 and bushing 624 are fixed relative to the sample line 217. A receiving plunger 626 is slideably housed in the center aperture of the bushing 624. Bushing 624 further includes a packing seal (not shown) to keep contaminants from the longitudinal aperture of the bushing. Plunger 626 has generally the same diameter as the mandrel 300 of the sample carrier 155. Plunger 626 is biased toward the drive assembly 610 (rightwardly in
It is desired that the plunger 626 not restrict the fluid transmission at the sample point. Aperture 633 allows the fluid to flow in the sample line 217 past the sample loader 625. This allows the sampling system, see e.g., 230 in
In operation, a new, unloaded sample carrier 155 is positioned intermediate the collars 612, 622. Drive assembly 610 moves laterally (leftwardly in
The mud pit 134 (
Carrier extraction unit 160 includes an identification system 925 for identifying the carrier 155. Carriers may not arrive at the surface or be removed from the mud in the order that they were loaded with samples. The identification system 925 is a bar code reader for reading the bar code printed on the carrier, in an embodiment. The ID system 925 is an RF communication system, in an embodiment with the carrier having an RFID. The RF communication system may further download the data stored in the RFID tag. This data may include the sequential number of the carrier, the depth, the pressure, and the temperature at which the sample was taken. Moreover, the data may be data from other downhole sensors and logging equipment. That is, the carrier may be the communication system that moves the data from downhole logging. Logging includes measurement-while-drilling (MWD) and logging-while-drilling (LWD) systems that provide wellbore directional surveys, petrophysical well logs, and drilling information in essentially real time while drilling. The instrumented, sensor containing drill collar 124 (
The unit 160, in an embodiment, includes an in-carrier analysis device 927. In an embodiment, device 927 includes a scale of weighing the carrier 155 with sample. The carrier 155 may further be transparent to certain tests. In an embodiment, the carrier 155 is transparent to X-rays. In an embodiment, the carrier 155 is transparent to visible light. In the alternative, the carrier may have a distinct reading in an analysis, which allows the in-carrier analysis to be performed with a correction for the carrier reading. Examples of types of in-carrier testing include optical techniques that assess absorbance, and fluorescence. Additional examples include x-ray and infrared transmissions to determine molecular weight, SARA (Saturates, Aromatics, Resins, Asphaltenes), and heavy metals (Ni, V, Zn). Moreover, the mandrel 300 can be manufactured from a material that has a resonant frequency that allows for investigation of density and viscosity of the sample while still in the carrier.
The system 160 includes, in an embodiment, a sample extractor 1001 that removes the sample from the carrier 155 and delivers the extracted sample to an analyzer 1005. The sample extractor 1001 and analyzer are discussed in greater detail below with reference to
The analyzer 1005, in various embodiments, performs testing of formation fluid samples. As used herein fluid means both liquids and gases due to the phase changes at different pressures, volumes, and temperatures. In an embodiment, the analyzer performs gas chromatography. As the sample carrier 155 transports a sample to the surface at its sample pressure and volume, the sample need not be reconstituted to its original pressure and volume before being analyzed.
The extractor 1001, in an embodiment, removes the sample from the carrier 155 using a solvent that is used in the analysis of the sample. In an example, the source provides a solvent, such as CS2 or CCl4, to the inlet port 1013. The inlet port 1013 injects the solvent into the sample while moving the sample to the outlet port 1015. The outlet port 1015 moves the sample with solvent to the analyzer 1005. The analyzer 1005 performs infrared, gas composition, or molecular weight analysis. In an embodiment, the analyzer 1005 further includes a gas chromatograph.
While described above as a down hole sampling system that releases the carriers 155 into the drilling mud for return to the surface, it is within the scope of an embodiment of the present invention to store the carriers 155 down hole and retrieve the samples at a later time. For example, the sample carriers 155 are loaded as described herein and returned to their magazine. In a further embodiment, the downhole tool 124 includes a store for the sample carriers 155. An example of a store is a container in the downhole tool 124 into which the loaded carriers 225 are ejected. This container could be a box fixed to the outer wall of the downhole tool 124 that does not interfere with the drill string 108. In this example, the carriers 155 are retrieved after each bit run after the downhole tool 124 returns to the surface.
The present disclosure provides methods and apparatus for collecting, preserving, identifying, retaining, transporting to the surface, and analyzing fluid samples from subterranean formations. The apparatus may have numerous carriers 155 that allow sampling at regular intervals while drilling. For example, a sample could be taken every X feet, e.g., every 10 or 100 feet. In other applications, the sampling may be done at a greater frequency at certain formations. The sample carriers 155 can be color coded or numbered such that they are identifiable with the bore location whereat each individual sample carrier was loaded with a sample. Sampling may be skipped at other formations depending on the formation and other data. The present sampling provided the opportunity to make drilling related decisions and reservoir management decisions at the drill site as the samples are retrieved at the drill site and can be analyzed at the drill site using equipment that only needs to be field hardened and not downhole compatible. For example, well casing options can be determined at the time the well is being drilled to prevent permanently sealing a possibly promising formation on the way past this formation. This decision can be made based on samples provided as described herein. The present sampling system should reduce the number of drill stem tests. Accordingly, the pace of drilling is increased by removing some drill down time, which should reduce drilling costs.
References in the specification to “one embodiment”, “an embodiment”, “an example embodiment”, etc., indicate that the embodiment described may include a particular feature, structure, or characteristic, but every embodiment may not necessarily include the particular feature, structure, or characteristic. Moreover, such phrases are not necessarily referring to the same embodiment. Further, when a particular feature, structure, or characteristic is described in connection with an embodiment, it is submitted that it is within the knowledge of one skilled in the art to affect such feature, structure, or characteristic in connection with other embodiments whether or not explicitly described.
The Abstract is provided to comply with 37 C.F.R. Section 1.72(b) requiring an abstract that will allow the reader to ascertain the nature and gist of the technical disclosure. It is submitted with the understanding that it will not be used to limit or interpret the scope or meaning of the claims.
In view of the wide variety of permutations to the embodiments described herein, this detailed description is intended to be illustrative only, and should not be taken as limiting the scope of the invention. What is claimed as the invention, therefore, is all such modifications as may come within the scope and spirit of the following claims and equivalents thereto. Therefore, the specification and drawings are to be regarded in an illustrative rather than a restrictive sense.
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|U.S. Classification||166/264, 166/100, 73/152.23, 175/233, 175/60|
|Cooperative Classification||E21B49/10, E21B49/086|
|European Classification||E21B49/08S, E21B49/10|
|Mar 3, 2006||AS||Assignment|
Owner name: HALLIBURTON ENERGY SERVICES, INC., TEXAS
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:PELLETIER, MICHAEL T.;WELCH, JOHN C.;MENEZES, CLIVE;REEL/FRAME:017651/0835
Effective date: 20060227
|Dec 28, 2010||CC||Certificate of correction|
|Jan 28, 2014||FPAY||Fee payment|
Year of fee payment: 4